Systems and methods for sidetracking operations

ABSTRACT

A bottomhole assembly for performing a sidetracking operation in a casing of a wellbore. A fluid intensifier is configured to receive fluid and configured to increase a pressure of the fluid. A fluid jetting nozzle is associated with a body of the bottomhole assembly. A fluid jetting nozzle is fluidly coupled to the fluid intensifier and is configured to receive pressurized fluid from the fluid intensifier. A fluid jetting nozzle is configured to cut a window into the casing via the pressurized fluid. A side arm is movable between a closed position wherein the side arm is retracted and a guiding position wherein the side arm is extended. The side arm is configured to contact the casing in the guiding position to guide the body within the casing. A hook is configured to couple to the cut window and remove the cut window from the casing.

BACKGROUND

Multilateral wells may be formed by performing a sidetracking operationto form a secondary wellbore from a primary wellbore. In conventionalsystems, sidetracking operations require milling assemblies to cut awindow into a casing of the primary wellbore. Milling assemblies requiresignificant time to operate and are therefore costly. Further, the useof milling assemblies requires human intervention during milling andtherefore is prone to human error.

Accordingly, a need exists for alternative systems and methods forsidetracking operations that are time-effective and rely less on humanintervention.

BRIEF SUMMARY

According to the subject matter of the present disclosure, a bottomholeassembly is described for performing a sidetracking operation in acasing of a wellbore. The assembly includes a body, a fluid intensifier,a fluid jetting nozzle, a side arm, and a hook. The fluid intensifier isconfigured to receive fluid and configured to increase a pressure of thefluid. The fluid jetting nozzle is associated with the body. The fluidjetting nozzle is fluidly coupled to the fluid intensifier and isconfigured to receive pressurized fluid from the fluid intensifier. Thefluid jetting nozzle is configured to cut a window into the casing viathe pressurized fluid. The side arm is movable between a closed positionwherein the side arm is retracted and a guiding position wherein theside arm is extended. The side arm is configured to contact the casingin the guiding position to guide the body within the casing. The hookdisposed on the body and configured to couple to the cut window andremove the cut window from the casing.

In accordance with another embodiment of the present disclosure, amethod is described for performing a sidetracking operation in a casingof a wellbore. The method includes guiding a body of a bottomholeassembly within the casing via a side arm extending from the body incontact with the casing. The method further includes descending the bodyto a cutting depth, the cutting depth being a predetermined depth withinthe casing for performing the sidetracking operation. The method furtherincludes operatively driving a fluid intensifier of the bottomholeassembly to a power supply of the bottomhole assembly. The methodfurther includes increasing a pressure of a fluid in the fluidintensifier. The method further includes cutting a window into thecasing via a fluid jetting nozzle associated with the body, the fluidjetting nozzle being fluidly coupled to the fluid intensifier andconfigured to receive pressurized fluid from the fluid intensifier. Themethod further includes coupling a hook disposed on the body into thecut window and removing the cut window from the casing.

In accordance with another embodiment of the present disclosure, abottomhole assembly is described for performing a sidetracking operationin a casing of a wellbore. The assembly includes a body, a fluidintensifier, a fluid jetting nozzle associated with the body, a sidearm, a hook disposed on the body, and a telemetry system. The fluidintensifier is configured to receive fluid and is configured to increasea pressure of the fluid. The fluid jetting nozzle is fluidly coupled tothe fluid intensifier and is configured to receive pressurized fluidfrom the fluid intensifier. The side arm is movable between a closedposition where the side arm is retracted and a guiding position wherethe side arm is extended. The side arm is configured to contact thecasing in the guiding position to guide the body within the casing. Thetelemetry system is communicatively coupled to the body, to the fluidintensifier, to the fluid jetting nozzle, and to the side arm. Thetelemetry system is configured to communicate with the body to descendthe body to a cutting depth, the cutting depth being a predetermineddepth within the casing for performing the sidetracking operation. Thetelemetry system is further configured to communicate with the fluidjetting nozzle to cut a window into the casing via the pressurizedfluid. The telemetry system is further configured to communicate withthe hook to couple to the cut window and remove the cut window from thecasing.

BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS

The following detailed description of specific embodiments of thepresent disclosure can be best understood when read in conjunction withthe following drawings, where like structure is indicated with likereference numerals and in which:

FIG. 1 illustrates a bottomhole assembly (BHA) within a casing of awellbore, according to some embodiments;

FIG. 2 illustrates a guiding profile that may be removably coupled tothe BHA of FIG. 1 , according to some embodiments;

FIG. 3 illustrates the BHA of FIG. 1 in a sidetracking operation,according to some embodiments;

FIG. 4 illustrates the BHA of FIG. 1 continuing in the sidetrackingoperation, according to some embodiments;

FIG. 5 illustrates BHA of FIG. 1 continuing in the sidetrackingoperation, according to some embodiments; and

FIG. 6 illustrates an example sidetracking operation method, accordingto some embodiments.

DETAILED DESCRIPTION

Sidetracking is the operation of drilling a secondary wellbore from anoriginal wellbore. Sidetracking allows for the bypassing of sections ofthe original wellbore that are unable to be used. Sidetracking is alsoused to explore geologic resources proximate to the original wellbore.To begin the sidetracking operation, a window must be removed from acasing within the original wellbore to provide access for a drill. Thelocation of the window is the point in which the secondary wellboredeviates from the original wellbore.

Referring initially to FIG. 1 , a system 100 for performing asidetracking operation is shown according to the some embodiments. Thesystem 100 includes a wellbore 102. The wellbore 102 is a drilled hole,or borehole, extending from the surface used to aid in the explorationand recovery of oil and gas. The wellbore 102 may include a casing 104which extends through the wellbore 102. The casing 104 isolatesequipment used to recover recourses and the recovered resources withinthe casing 104 from an exterior of the casing 104. The casing isconfigured to withstand a variety of external forces caused fromcollapsing, bursting, tensile failure, and the like. The casing 104 maybe constructed of steel, stainless steel, aluminum, titanium,fiberglass, or other materials of the like. An exterior wall of thecasing 104 may be enclosed (e.g., surrounded) with cement in order tofix the casing 104 in place within the wellbore 102.

The system 100 may include a bottomhole assembly (BHA) 106. The BHA 106may be positioned on a lower portion of a drillstring (not shown) andmay be positioned within the casing 104. The BHA 106 may providedirectional drilling within the casing 104 by providing a large forceonto a drilling bit (not shown). The BHA 106 is configured to withstanda harsh drilling environment within the casing 104 and may be furtherconfigured to facilitate communication with the surface. As discussed ingreater detail herein, the BHA 106 includes several components whichenable the sidetracking operation to be performed. In system 100, theBHA 106 may be configured to cut a window into the casing 104 and thenretrieving that window before performing the sidetracking operation. Acenter axis of the BHA 106 defines a longitudinal axis α along a lengthof the BHA 106.

The system 100 may include a drill pipe 108 positioned on an upperportion of the BHA 106. The drill pipe 108 extends from the upperportion of the BHA 106 to a portion of the drillstring. Accordingly, thedrill pipe 108 mechanically couples (e.g., integrates, connects) thedrillstring to the BHA 106. The BHA 106 further includes a body 109coupled to the drill pipe 108. The body 109 extends from the drill pipe108 to a bottom surface of the BHA 106. The body 109 may be centered onthe longitudinal axis α. As discussed in greater detail herein,components of the BHA 106 may be positioned within the body 109.

The BHA 106 may include a controller 110 (e.g., processor, computingunit). The controller 110 may be configured to load executable programsfor the BHA 106 and to execute the executable programs. As discussed ingreater detail herein, the BHA 106 may be communicatively coupled to thevarious components of the BHA 106 and may be configured to control theoperation of these various components.

The controller 110 may include a telemetry system 110 a (e.g.,communication system) positioned within the BHA 106. The telemetrysystem 110 a facilitates for communication between the controller 110and the surface. In this way, the telemetry system 110 a providescommunication between the BHA 106 and the operators of the system 100.The telemetry system 110 a may be configured to generate and/or receivesignals in the form of pressure pulses within a fluid medium. Further,the controller 110 may provide information (e.g., sensor readings,report issues) to the operators. This may be advantageous as theoperation of the BHA 106 may be controlled and monitored by theoperators. The fluid medium in which the pressure pulses are emittedwithin may be referred to as mud. The mud may consist of drilling fluid(e.g., cutting fluid), suspended solids, emulsified water, or oil whichsurrounds the BHA 106 and the drillstring. Other approaches forcommunicating the controller 110 to the surface may also be utilized.

The BHA 106 may further include a side arm 111 movable between a closedposition and a guiding position. The side arm 111 may be translated by amotor (not shown) within the BHA 106. In the closed position, the sidearm 111 may be at least partially retracted within the body 109 or maybe adjacent to the body 109 (e.g., extends parallel to the body 109).This may be advantageous as it mitigates damage to the side arm 111during the translation of the BHA 106 within the wellbore 102. In theguiding position, the side arm 111 extends away from the body 109 andextends towards the casing 104. In the guiding position, the side arm111 guides the BHA 106 within the casing 104 by translating away fromthe casing 104 by a distance D. Based on an angle θ of the side arm 111relative to the longitudinal axis α, the BHA 106 may determine thedistance D away from a wall of the casing 104. In some embodiments, inthe guiding position, the side arm 111 may be translated 5° to 10°relative to the longitudinal axis α. In some embodiments, in the guidingposition, the side arm 111 may be translated 10° to 25° relative to thelongitudinal axis α. In some embodiments, in the guiding position, theside arm 111 may be translated 25° to 60° relative to the longitudinalaxis α.

The side arm 111 may be communicatively coupled to the controller 110.The controller 110 may receive a signal from the surface to move the BHA106 a specified distance away from the casing 104. The controller 110may then provide a signal to the side arm to translate a specified anglethat may be mapped to (e.g., related to, determined to be equal to) thespecified distance away from the casing 104.

In some embodiments, the BHA 106 includes a plurality of side arms. Forexample, and as shown in FIG. 3 , the BHA 106 may include a second sidearm 111 a that co-operates with the side arm 111 to guide the BHA 106within the casing 104. The plurality of side arms are communicativelycoupled to the controller 110 in order to provide additional referencespoints to guide the BHA 106 within the casing 104.

Referring again to FIG. 1 , the BHA 106 may further include an abrasivematerial supply 112 positioned within the lower portion of the BHA 106.The abrasive material in the abrasive material supply 112 may beconstructed of a mineral such a garnet, staurolite, sand, or any othersuitable abrasive. In embodiments, the abrasive material supply 112 maybe positioned within the upper portion of the BHA 106. In embodiments,the abrasive material supply 112 may be positioned within thedrillstring.

The system 100 may further include a fluid supply (not shown). The fluidsupply extends along a length of the drillstring and along a portion ofthe BHA 106. The fluid supply provides fluid (e.g., water, cuttingfluid) from the surface to the BHA 106.

The BHA 106 may further include a fluid intensifier 114 positionedwithin the lower portion of the BHA 106. The fluid intensifier 114 maybe in fluid communication with the fluid supply. The fluid intensifier114 greatly increases a pressure of the received fluid through anintensifier pump. In embodiments, the fluid intensifier 114 increasesthe pressure of the fluid to be between 30,000 to 40,000 PSI. Inembodiments, the fluid intensifier 114 increases the pressure of thefluid to be between 40,000 to 60,000 PSI. In embodiments, the fluidintensifier 114 increases the pressure of the fluid to be between 60,000to 100,000 PSI. In embodiments, the fluid intensifier 114 may bepositioned within the upper portion of the BHA 106. In embodiments, thefluid intensifier 114 is positioned within the drillstring. Thecontroller 110 may be communicatively coupled to the fluid intensifier114 and thereby controls the operation of the fluid intensifier 114(e.g., activation of the fluid intensifier, the desired pressure rangeof the fluid).

The BHA 106 may further include a power supply 115 (e.g., battery, powersource) positioned within the BHA 106. The power supply 115 may beoperatively coupled to the fluid intensifier 114, thereby providingpower to the fluid intensifier 114 in order for the fluid intensifier114 to operate. The controller 110 may be communicatively coupled to thepower supply 115 and thereby controls the operation of the power supply115 (e.g., activation of the fluid intensifier, the desired pressurerange of the fluid).

The BHA 106 may further include a mixing chamber 116 which may bepositioned within the lower portion of the BHA 106. The mixing chamber116 may be fluidly coupled to the abrasive material supply 112 and thefluid intensifier 114. The mixing chamber 116 receives abrasive materialfrom the abrasive material supply 112 and the pressurized fluid from thefluid intensifier 114 and mixes the abrasive material with thepressurized fluid to form an abrasive pressurized fluid. In embodiments,the mixing chamber 116 may be positioned within the upper portion of theBHA 106. In embodiments, the mixing chamber 116 may be positioned withinthe drillstring. The controller 110 may be communicatively coupled tothe mixing chamber 116 and thereby controls the operation of the mixingchamber 116 (e.g., activation of the mixing chamber 116, the desiredmixing ratio of the abrasive material relative to the fluid volume).

By using the fluid intensifier 114 with the abrasive material supply112, the BHA 106 may be capable of producing an abrasive pressurizedfluid capable of cutting into the casing 104. This is advantageous asspecial pump equipment capable of handling a harsh environment is notrequired. Further, by using the fluid intensifier 114 within the BHA106, there is not a need for pumps to be placed on the surface whichtransmit pressurized fluid along the entire length of the drillstring.This is advantageous as it increases the safety and operationalefficiency of the cutting operation.

The BHA 106 may further include a fluid jetting nozzle 118 which may bepositioned within the lower portion of the BHA 106. The fluid jettingnozzle 118 may be movable between a retracted position and a cuttingposition. In the retracted position, the fluid jetting nozzle 118 may bepositioned within the body 109 of the BHA 106. In the cutting position,the fluid jetting nozzle 118 extends away from the body 109 of the BHA106. The fluid jetting nozzle 118 may be fluidly coupled to the mixingchamber 116 and may be configured to receive abrasive pressurized fluidfrom the mixing chamber 116. In embodiments, the fluid jetting nozzle118 receives pressurized fluid directly from the fluid intensifier 114.The fluid jetting nozzle 118 directs the flow of the received abrasivepressurized fluid to the casing 104, thereby cutting a window 104 a intothe casing 104. In embodiments, the fluid jetting nozzle 118 directs thefluid generally orthogonal to the longitudinal axis α. However, thefluid jetting nozzle 118 may be movable to dispense fluid ± 45° relativeto an axis orthogonal to the longitudinal axis α. In embodiments, thefluid jetting nozzle 118 may be positioned within the upper portion ofthe BHA 106. The controller 110 may be communicatively coupled to thefluid jetting nozzle 118 and thereby controls the operation of the fluidjetting nozzle 118 (e.g., activation of the fluid jetting nozzle 118,the desired direction of the fluid stream dispensed by the fluid jettingnozzle 118).

The BHA 106 may further include hooks 122 positioned on a mid-portion ofthe BHA 106. The hooks 122 are movable between a retracted position anda retrieving position. In the retracted position, the hooks 122 are atleast partially positioned within the body 109. This is advantageous asit mitigates damage to the hooks 122 during the translation of the BHA106 within the wellbore 102. In the retrieving position, the hooks 122extend away from the body 109 and towards the casing 104. After thewindow 104 a has been cut by the fluid jetting nozzle 118, the hooks 122couple to the cut window 104 a. In embodiments, after coupling to thewindow 104 a, the hooks 122 move away from the casing 104, therebyremoving the window 104 a from the casing 104. In embodiments, aftercoupling to the window 104 a, the BHA 106 translates away from thecasing 104, thereby removing the window 104 a from the casing 104. Thecontroller 110 may be communicatively coupled to the hooks 122 andthereby controls the operation of the hooks 122 (e.g., moving the hooks122 between the retracted position and the retrieving position,activating the hooks 122 to couple to the window).

In embodiments, the hooks 122 are a plurality of drills which couple tothe window 104 a by drilling into the window 104 a. In some embodiments,the hooks 122 are clamps, latches, or the like which couple to thewindow 104 a.

The BHA 106 may further include a drilling jar 120 which may positionedon an upper portion of the BHA 106. The drilling jar 120 may be amechanism in which generates an impact force. In embodiments, the impactforce may be directed to a path orthogonal to the longitudinal axis α.In embodiments, the impact force may be directed to a path along thelongitudinal axis α. In embodiments, the impact force may be generatedby a mechanical mechanism or by a hydraulic mechanism. The drilling jaris configured to have restricted range of motion within the BHA 106.During the retrieval operation of the window 104 a by the hooks 122, thedrilling jar 120 applies the impact force upon the hooks 122 in order tobreak down the cement behind the casing 104. In this way, an opening fora secondary wellbore may be formed from the wellbore 102. Inembodiments, the drilling jar 120 may be positioned within the lowerportion of the BHA 106. The controller 110 may be communicativelycoupled to the drilling jar 120 and thereby controls the operation ofthe drilling jar 120 (e.g., activation of the drilling jar 120,direction of the impact force by the drilling jar 120).

Referring now to FIG. 2 , a guiding system 200 is shown, according tosome embodiments. As discussed in greater detail herein, in someembodiments the guiding system 200 may be used in conjunction with thesystem 100 during the sidetracking operation. The guiding system 200 mayinclude a primary latching mechanism 202 on a top surface of the guidingsystem 200. The primary latching mechanism 202 may be removably coupledto a bottom surface of the BHA 106. As discussed in greater detailherein, when the BHA 106 is coupled to the guiding system 200, the BHAcontrols the translation of the guiding system 200 within the casing104.

The guiding system 200 may further include mounting latches 204positioned on a bottom surface of the guiding system 200. As discussedin greater detail herein, the mounting latches 204 facilitate for theguiding system 200 to mount onto the casing 104. The mounting latches204 are retractable into a body of the guiding system 200 in order tomitigate damage to the mounting latches 204 during translation of theguiding system 200.

The guiding system 200 may further include inflatable packers 206. Afterthe mounting latches 204 mount onto the casing 104, the inflatablepackers 206 are inflated. The inflatable packers 206 isolate a bottomportion of the wellbore 102 beneath the guiding system 200 from a topportion of the wellbore 102 above the guiding system 200 by creating a360° seal. This is advantageous as it prevents pressure differencesbetween the bottom portion of the wellbore 102 and the top portion ofthe wellbore 102 from disrupting the cutting operation. Further, itprevents shavings from the cutting operation from falling into thebottom portion of the wellbore 102 as the shavings are caught by theguiding system 200.

The guiding system 200 may further include a guiding profile 208. Theguiding profile 208 may be a cable (e.g., wire, net) extending from afirst wall 205 a of the guiding system 200 to a second wall 205 b of theguiding system 200. As discussed in greater detail herein, the guidingprofile 208 guides the BHA 106 to a correct cutting depth before thecutting operation. The guiding profile 208 may be constructed of aflexible material (e.g., rubber). This is advantageous as it allows forthe BHA 106 to make contact with the guiding profile 208 withoutdamaging the BHA 106.

After the cutting operation of the BHA 106 is conducted, the guidingsystem 200 may be removed from the wellbore 102. The guiding system 200may be coupled to a retrieving tool via the primary latching mechanism202. During retrieval the force of removing the guiding system 200deflates the inflatable packers 206. In some situations, the retrievingtool may not properly couple to the primary latching mechanism 202(e.g., due to not making a proper clamping mechanism, cannot accuratelyfind the primary latching mechanism 202). To ensure retrieval, theguiding system 200 may further include a secondary latching mechanism210 positioned on the first wall 205 a of the guiding system 200. Inthis way, the retrieval device has a secondary location to latch ontothe guiding system 200 for retrieval.

In scenarios where the secondary latching mechanism 210 is difficult tolatch onto, the guiding system 200 may further include a tertiarylatching mechanism 212 positioned on the second wall 205 b. In thesescenarios, the retrieval tool latches onto both the secondary latchingmechanism 210 and the tertiary latching mechanism 212. This results inan equal force to be applied onto the guiding system 200 enough todeflate the inflatable packers 206 and remove the guiding system 200from the wellbore 102.

Now referring to FIG. 3 , the BHA 106 and the guiding system 200 areshown during a sidetracking operation 300, according to someembodiments. The sidetracking operation 300 begins with the guidingsystem 200 being removably coupled to the BHA 106 via the primarylatching mechanism 202. The side arm 111 and the side arm 111 a are usedto guide a position of the BHA 106 and the guiding system 200 within thecasing 104. The side arm 111 and the side arm 111 a extend away from thebody 109 by a specified angle. This results in the BHA 106 and theguiding system 200 to be separated away from a point of thecircumference of the casing 104 by a specified distance. In this way,the BHA 106 is at a specified location within the casing 104. Thedesired position of the BHA 106 within the casing 104 may becommunicated to the controller 110 via the telemetry system 110 a fromthe surface. During the guiding process, the hooks 122 are in theretracted state in the body 109.

Through the telemetry system 110 a, the controller 110 provides thedepth of the BHA 106 to the surface. Accordingly, the telemetry system110 a communicates when the BHA 106 reaches a cutting depth C_(D). Thecutting depth C_(D) is a depth measured along a center axis of thewellbore 102 from the surface. In embodiments, the cutting depth C_(D)may be pre-programmed so that the BHA 106 is configured to translateautomatically until it reaches the cutting depth C_(D).

When the cutting depth C_(D) is reached, the mounting latches 204 areactivated, thereby coupling the guiding system 200 to the casing 104. Inembodiments, the controller 110 of the BHA 106 may be communicativelycoupled to the guiding system 200, thereby instructing the mountinglatches 204 to be activated. In embodiments, the guiding system 200includes a respective controller and telemetry system that areconfigured to communicate with the BHA 106 and the surface.

Once the guiding system 200 is coupled to the casing, the inflatablepackers 206 are inflated. When the inflatable packers 206 are inflated,the bottom portion of the wellbore 102 is isolated from the top portionof the wellbore 102. This prevents pressure differences between theportions from effecting the cutting operation, diluting pressure pulsesfrom the surface from being received by the telemetry system 110 a, andpreventing shavings from the cutting operation from dropping into thebottom portion of the wellbore 102. Further, the guiding system 200 maybe used after the sidetracking operation 300 to maintain isolationbetween the bottom portion of the wellbore 102 and the top portion ofthe wellbore 102 to avoid pressure differences disrupting the drillingof the secondary wellbore.

At this point, the side arms 111 return to the closed position and theBHA 106 performs a slack-off test. The slack-off test consists of theBHA 106 applying a pressure onto the guiding system 200 to ensure theinflatable packers 206 are properly set onto the casing 104. If theinflatable packers 206 are properly set, the BHA 106 will removablycouple from the guiding system 200.

Referring now to FIG. 4 , the sidetracking operation 300 continues withthe side arms 111 being returned to the guiding position and separatingthe BHA 106 away from the guiding system 200. The side arms 111 thenguide the BHA 106 to a cutting position. The cutting position is alocation within the casing 104 proximate to the cutting depth C_(D).Once the BHA 106 is at the cutting position, the cutting operation nowcommences. During the cutting operation, the guiding profile 208prevents damage to the BHA 106 in case of collision between the guidingsystem 200 and the BHA 106.

During the cutting operation, the power supply 115 provides power to thefluid intensifier 114. The fluid intensifier 114 begins increasing thepressure of the received fluid from the fluid supply. The pressurizedfluid may be provided to the mixing chamber 116. Additionally, theabrasive material supply 112 provides abrasive material to the mixingchamber 116. The mixing chamber 116 mixes the pressurized fluid withabrasive material to form a pressurized abrasive fluid. The pressurizedabrasive fluid may be then provided to the fluid jetting nozzle 118.

The fluid jetting nozzle 118 begins to cut the window 104 a into thecasing 104. In conventional systems, a cutting profile is defined duringthe cutting operation. This may lead to human error and in an untimelyprocess. In certain embodiments, the cutting profile of the window 104 ais pre-programmed prior to the cutting operation. In this way, thecutting operation is timely and not prone to human error. While cutting,the BHA 106 may rotate in order to dispense heat created during thecutting process. In this way, the BHA 106 may remain cool during thecutting process.

Referring now to FIG. 5 , the sidetracking operation 300 is shown duringthe retrieval process. During the retrieval process, the fluid jettingnozzle 118 returns to its retracted position. Further, the hooks 122move to the retrieving position in which the hooks 122 extend away fromthe body 109. In embodiments where the hooks 122 are a plurality ofdrills, the hooks 122 drill into the window 104 a. While removing thewindow 104 a from the casing 104, the drilling jar 120 applies an impactforce onto the hook 122, thereby applying the impact force onto thecement surrounding the casing 104. This is in order to break the cementbehind the window 104 a. In this way, an opening is formed for thesecondary wellbore. With the window 104 a removed from the casing, theBHA 106 returns to the surface with the window 104 a being coupled tothe hooks 122. In embodiments, the drilling jar 120 applies the impactforce onto the cement surrounding the casing 104 after removing thewindow 104 a from the casing 104.

While returning to the surface the side arms 111 are still in theguiding position in order to guide the BHA 106. After lateral drillingof the secondary wellbore is completed, the guiding system 200 may alsobe removed by using either the primary latching mechanism 202, thesecondary latching mechanism 210 and/or the tertiary latching mechanism212.

Referring now to FIG. 6 , a method 600 for performing a sidetrackingoperation is shown. The method 600 may be performed by a BHA (e.g., suchas BHA 106) in a wellbore (e.g., such as wellbore 102). The steps ofmethod 600 may be performed by a controller (e.g., such as controller110) positioned within the BHA. The controller may be configured tocommunicate with the surface and with various components of the BHA viaa telemetry system (e.g., such as telemetry system 110 a).

At step 602, a body of the BHA (e.g., such as body 109) may be guidedwithin a casing (e.g., such as casing 104) of the wellbore. The body maybe guided by side arms (e.g., such as side arm 111 and side arm 111 a)which place the body in a determined position within the casing. Theposition of the body may be controlled by a controller (e.g., such ascontroller 110) positioned with the BHA. The controller communicateswith the surface via a telemetry system (e.g., such as telemetry system110 a).

At step 604, the body descends to a cutting depth (e.g., such as cuttingdepth C_(D)). In some embodiments, the body may be coupled to a guidingsystem (e.g., such as guiding system 200). At the cutting depth, theguiding system may be coupled to the casing and removably detached fromthe body. Additionally, the guiding system may inflate inflatablepackers (e.g., such as inflatable packers 206), in order to isolate alower portion of the wellbore from a top portion of the wellbore.

At step 606, power from a power supply (e.g., such as power supply 115)may be provided to a fluid intensifier (e.g., such as fluid intensifier114) of the BHA. At step 608, a pressure of a fluid received in the BHAmay be then increased by the fluid intensifier. The pressurized fluidmay be mixed with abrasive material supplied by an abrasive materialsupply (e.g. such as abrasive material supply 112) in a mixing chamber(e.g., such as mixing chamber 116).

At step 610, a fluid jetting nozzle (e.g., such as fluid jetting nozzle118) of the BHA receives pressurized abrasive fluid from the mixingchamber. The fluid jetting nozzle then cuts a window into the casingwith the pressurized abrasive fluid. The cutting path of the fluidjetting nozzle may be preprogrammed prior to the cutting operation. Thisis advantageous as it reduces the time of the cutting process andreduces human error.

At step 612, a hook (e.g., such as hooks 122) of the BHA may be coupledinto the window. At step 614, the cut window may be then removed fromthe casing. During the removal of the cut window, a drilling jar (e.g.,such as drilling jar 120) applies an impact force onto the hook therebyapplying the impact force onto the cement behind the window. In thisway, the cement may be broken.

For the purposes of describing and defining the present invention, it isnoted that reference herein to a variable being a “function” of aparameter or another variable is not intended to denote that thevariable is exclusively a function of the listed parameter or variable.Rather, reference herein to a variable that is a “function” of a listedparameter is intended to be open ended such that the variable may be afunction of a single parameter or a plurality of parameters.

It is also noted that recitations herein of “at least one” component,element, etc., should not be used to create an inference that thealternative use of the articles “a” or “an” should be limited to asingle component, element, etc. For example, the fluid jetting nozzle118 may be a plurality of fluid jetting nozzles.

It is noted that recitations herein of a component of the presentdisclosure being “configured” or “programmed” in a particular way, toembody a particular property, or to function in a particular manner, arestructural recitations, as opposed to recitations of intended use. Morespecifically, the references herein to the manner in which a componentis “configured” or “programmed” denotes an existing physical conditionof the component and, as such, is to be taken as a definite recitationof the structural characteristics of the component.

It is noted that terms like “preferably,” “commonly,” and “typically,”when utilized herein, are not utilized to limit the scope of the claimedinvention or to imply that certain features are critical, essential, oreven important to the structure or function of the claimed invention.Rather, these terms are merely intended to identify particular aspectsof an embodiment of the present disclosure or to emphasize alternativeor additional features that may or may not be utilized in a particularembodiment of the present disclosure.

For the purposes of describing and defining the present invention it isnoted that the terms “substantially” and “approximately” are utilizedherein to represent the inherent degree of uncertainty that may beattributed to any quantitative comparison, value, measurement, or otherrepresentation. The terms “substantially” and “approximately” are alsoutilized herein to represent the degree by which a quantitativerepresentation may vary from a stated reference without resulting in achange in the basic function of the subject matter at issue.

One or more aspects of the present disclosure are described here. Afirst aspect of the present disclosure may include a bottomhole assemblyfor performing a sidetracking operation in a casing of a wellbore. Theassembly includes a body, a fluid intensifier configured to receivefluid and configured to increase a pressure of the fluid, a fluidjetting nozzle associated with the body, a side arm, and a hook disposedon the body. The fluid jetting nozzle is fluidly coupled to the fluidintensifier and configured to receive pressurized fluid from the fluidintensifier. The fluid jetting nozzle is configured to cut a window intothe casing via the pressurized fluid. The side arm movable between aclosed position wherein the side arm is retracted and a guiding positionwherein the side arm is extended. The side arm is configured to contactthe casing in the guiding position to guide the body within the casing.The hook is configured to couple to the cut window and remove the cutwindow from the casing.

A second aspect of the present disclosure may include the first aspect,wherein an end of the body is removably coupled to a guiding profile.

A third aspect of the present disclosure may include the first aspectand the second aspect, further including a drilling jar disposed withinthe body. The drilling jar is configured to generate an impact forceonto the hook when activated.

A fourth aspect of the present disclosure may include any of the firstaspect through the third aspect, further including a power supplyoperatively coupled to the fluid intensifier and configured tooperatively drive the fluid intensifier.

A fifth aspect of the present disclosure may include any of the firstaspect through the fourth aspect, further including an abrasive materialsupply and a mixing chamber fluidly coupled to the fluid intensifier andfluidly coupled to the fluid jetting nozzle. The mixing chamber isconfigured to receive abrasive material from the abrasive materialsupply, receive the pressurized fluid from the fluid intensifier, mixthe pressurized fluid and the abrasive material, and provide the mixedpressurized fluid to the fluid jetting nozzle.

A sixth aspect of the present disclosure may include any of the firstaspect through the fifth aspect, wherein the fluid jetting nozzle isdisposed on a lower end of the body.

A seventh aspect of the present disclosure may include any of the firstaspect through the sixth aspect, wherein the hook includes a pluralityof drills movable between a retracted position wherein the plurality ofdrills are retracted within the body and a retrieval position whereinthe plurality of drills are extended. The plurality of drills areconfigured to drill into the window to remove the window from thecasing.

An eighth aspect of the present disclosure may include any of the firstaspect through the seventh aspect, further including a second side armmovable between the closed position wherein the second side arm isretracted and the guiding position wherein the second side arm isextended. The second side arm is configured to contact the casing in theguiding position to guide the bottomhole assembly within the casing.Wherein a base portion of the side arm is positioned on a first side ofthe body, a base portion of the second side arm is positioned on asecond side of the body, and the second side arm and the side armco-operate to position the body within the casing.

A ninth aspect of the present disclosure may include any of the firstaspect through the eighth aspect, wherein the hook is positioned on thefirst side of the body.

A tenth aspect of the present disclosure may include a method forperforming a sidetracking operation in a casing of a wellbore. Themethod includes guiding a body of a bottomhole assembly within thecasing via a side arm extending from the body in contact with thecasing. The method further includes descending the body to a cuttingdepth. The cutting depth having a predetermined depth within the casingfor performing the sidetracking operation. The method further includesoperatively driving a fluid intensifier of the bottomhole assembly to apower supply of the bottomhole assembly. The method further includesincreasing a pressure of a fluid in the fluid intensifier. The methodfurther includes cutting a window into the casing via a fluid jettingnozzle associated with the body, the fluid jetting nozzle being fluidlycoupled to the fluid intensifier and configured to receive pressurizedfluid from the fluid intensifier. The method further includes coupling ahook disposed on the body into the cut window and removing the cutwindow from the casing.

An eleventh aspect of the present disclosure may include a tenth aspect,further including removably coupling a guiding profile to a lower end ofthe body and removably coupling the guiding profile to the casing andremovably decoupling the guiding profile from the lower end.

A twelfth aspect of the present disclosure may include any of the tenthaspect through the eleventh aspect, further including programming acutting path of the fluid jetting nozzle.

A thirteenth aspect of the present disclosure may include any of thetenth aspect through the twelfth aspect, further including operativelycoupling a telemetry system to the body, the fluid jetting nozzle, thepower supply, and the fluid intensifier.

A fourteenth aspect of the present disclosure may include any of thetenth aspect through the thirteenth aspect, further including providingabrasive material from an abrasive material supply disposed in thebottomhole assembly to a mixing chamber disposed in the bottomholeassembly, providing the pressurized fluid from the fluid intensifier tothe mixing chamber, mixing the pressurized fluid and the abrasivematerial in the mixing chamber, and providing the mixed pressurizedfluid to the fluid jetting nozzle.

A fifteenth aspect of the present disclosure may include any of thetenth aspect through the fourteenth aspect, further including generatingan impact force by activating a drilling jar disposed in the body ontothe hook.

A sixteenth aspect of the present disclosure may include any of thetenth aspect through the fifteenth aspect, wherein operatively couplingthe hook to the cut window is performed via a plurality of drills, theplurality of drills being movable between a retracted position whereinthe plurality of drills are retracted within the body and a retrievalposition wherein the plurality of drills are extended.

A seventeenth aspect of the present disclosure may include any of thetenth aspect through the sixteenth aspect, further including guiding thebody within the casing via a second side arm configured to contact thecasing. Wherein a base portion of the side arm is positioned on a firstside of the body, a base portion of the second side arm is positioned ona second side of the body, and the second side arm and the side armco-operate to position the body within the casing.

An eighteenth aspect of the present disclosure, may include a bottomholeassembly for performing a sidetracking operation in a casing of awellbore. The assembly including a body, a fluid intensifier, a fluidjetting nozzle associated with the body, a side arm, a hook disposed onthe body, and a telemetry system. The fluid intensifier is configured toreceive fluid and is configured to increase a pressure of the fluid. Thefluid jetting nozzle is fluidly coupled to the fluid intensifier and isconfigured to receive pressurized fluid from the fluid intensifier. Theside arm is movable between a closed position, wherein the side arm isretracted and a guiding position wherein the side arm is extended, theside arm is configured to contact the casing in the guiding position toguide the body within the casing. The telemetry system iscommunicatively coupled to the body, to the fluid intensifier, to thefluid jetting nozzle, and to the side arm. The telemetry system isconfigured to communicate with the body to descend the body to a cuttingdepth. The cutting depth being a predetermined depth within the casingfor performing the sidetracking operation. The telemetry system isfurther configured to communicate with the fluid jetting nozzle to cut awindow into the casing via the pressurized fluid. The telemetry systemis further configured to communicate with the hook to couple to the cutwindow and remove the cut window from the casing.

A nineteenth aspect of the present disclosure may include the eighteenthaspect, wherein the telemetry system is communicatively coupled to adrilling jar disposed within the body, and wherein the telemetry systemcommunicates with the drilling jar to generate an impact force onto thebody.

A twentieth aspect of the present disclosure may include any of theeighteenth aspect and the nineteenth aspect, wherein the telemetrysystem is communicatively coupled to an abrasive material supply and toa mixing chamber fluidly coupled to the fluid intensifier and fluidlycoupled to the fluid jetting nozzle. The telemetry system communicateswith the mixing chamber to receive abrasive material from the abrasivematerial supply, receive the pressurized fluid from the fluidintensifier, mix the pressurized fluid and the abrasive material, andprovide the mixed pressurized fluid to the fluid jetting nozzle.

Having described the subject matter of the present disclosure in detailand by reference to specific embodiments thereof, it is noted that thevarious details disclosed herein should not be taken to imply that thesedetails relate to elements that are essential components of the variousembodiments described herein, even in cases where a particular elementis illustrated in each of the drawings that accompany the presentdescription. Further, it will be apparent that modifications andvariations are possible without departing from the scope of the presentdisclosure, including, but not limited to, embodiments defined in theappended claims. More specifically, although some aspects of the presentdisclosure are identified herein as preferred or particularlyadvantageous, it is contemplated that the present disclosure is notnecessarily limited to these aspects.

It is noted that one or more of the following claims utilize the term“wherein” as a transitional phrase. For the purposes of defining thepresent invention, it is noted that this term is introduced in theclaims as an open-ended transitional phrase that is used to introduce arecitation of a series of characteristics of the structure and should beinterpreted in like manner as the more commonly used open-ended preambleterm “comprising.”

What is claimed is:
 1. A bottomhole assembly for performing asidetracking operation in a casing of a wellbore, the assemblycomprising: a body; a fluid intensifier configured to receive fluid andconfigured to increase a pressure of the fluid; a fluid jetting nozzleassociated with the body, the fluid jetting nozzle being fluidly coupledto the fluid intensifier and configured to receive pressurized fluidfrom the fluid intensifier, the fluid jetting nozzle configured to cut awindow into the casing via the pressurized fluid; a side arm movablebetween a closed position wherein the side arm is retracted and aguiding position wherein the side arm is extended, the side armconfigured to contact the casing in the guiding position to guide thebody within the casing; and a hook disposed on the body and configuredto couple to the cut window and remove the cut window from the casing.2. The assembly of claim 1, wherein an end of the body is removablycoupled to a guiding profile.
 3. The assembly of claim 1, furthercomprising a drilling jar disposed within the body, the drilling jarconfigured to generate an impact force onto the hook when activated. 4.The assembly of claim 1, further comprising a power supply operativelycoupled to the fluid intensifier and configured to operatively drive thefluid intensifier.
 5. The assembly of claim 1, further comprising: anabrasive material supply; and a mixing chamber fluidly coupled to thefluid intensifier and fluidly coupled to the fluid jetting nozzle, themixing chamber configured to: receive abrasive material from theabrasive material supply, receive the pressurized fluid from the fluidintensifier, mix the pressurized fluid and the abrasive material, andprovide the mixed pressurized fluid to the fluid jetting nozzle.
 6. Theassembly of claim 1, wherein the fluid jetting nozzle is disposed on alower end of the body.
 7. The assembly of claim 1, wherein the hookcomprises a plurality of drills movable between a retracted positionwherein the plurality of drills are retracted within the body and aretrieval position wherein the plurality of drills are extended, theplurality of drills configured to drill into the window to remove thewindow from the casing.
 8. The assembly of claim 1, further comprising asecond side arm movable between the closed position wherein the secondside arm is retracted and the guiding position wherein the second sidearm is extended, the second side arm configured to contact the casing inthe guiding position to guide the bottomhole assembly within the casing,wherein: a base portion of the side arm is positioned on a first side ofthe body, a base portion of the second side arm is positioned on asecond side of the body, and the second side arm and the side armco-operate to position the body within the casing.
 9. The assembly ofclaim 8, wherein the hook is positioned on the first side of the body.10. A method for performing a sidetracking operation in a casing of awellbore, the method comprising: guiding a body of a bottomhole assemblywithin the casing via a side arm extending from the body in contact withthe casing; descending the body to a cutting depth, the cutting depthbeing a predetermined depth within the casing for performing thesidetracking operation; operatively driving a fluid intensifier of thebottomhole assembly to a power supply of the bottomhole assembly;increasing a pressure of a fluid in the fluid intensifier; cutting awindow into the casing via a fluid jetting nozzle associated with thebody, the fluid jetting nozzle being fluidly coupled to the fluidintensifier and configured to receive pressurized fluid from the fluidintensifier; and coupling a hook disposed on the body into the cutwindow and removing the cut window from the casing.
 11. The method ofclaim 10, further comprising: removably coupling a guiding profile to alower end of the body; and removably coupling the guiding profile to thecasing and removably decoupling the guiding profile from the lower end .12. The method of claim 10, further comprising programming a cuttingpath of the fluid jetting nozzle.
 13. The method of claim 10, furthercomprising operatively coupling a telemetry system to the body, thefluid jetting nozzle, the power supply, and the fluid intensifier. 14.The method of claim 10, further comprising: providing abrasive materialfrom an abrasive material supply disposed in the bottomhole assembly toa mixing chamber disposed in the bottomhole assembly; providing thepressurized fluid from the fluid intensifier to the mixing chamber;mixing the pressurized fluid and the abrasive material in the mixingchamber, and providing the mixed pressurized fluid to the fluid jettingnozzle.
 15. The method of claim 10, further comprising generating animpact force by activating a drilling jar disposed in the body onto thehook.
 16. The method of claim 10, wherein operatively coupling the hookto the cut window is performed via a plurality of drills, the pluralityof drills being movable between a retracted position wherein theplurality of drills are retracted within the body and a retrievalposition wherein the plurality of drills are extended.
 17. The method ofclaim 10, further comprising guiding the body within the casing via asecond side arm configured to contact the casing, wherein: a baseportion of the side arm is positioned on a first side of the body, abase portion of the second side arm is positioned on a second side ofthe body, and the second side arm and the side arm co-operate toposition the body within the casing.
 18. A bottomhole assembly forperforming a sidetracking operation in a casing of a wellbore, theassembly comprising: a body; a fluid intensifier; a fluid jetting nozzleassociated with the body; a side arm; a hook disposed on the body; and atelemetry system, wherein: the fluid intensifier is configured toreceive fluid and is configured to increase a pressure of the fluid; thefluid jetting nozzle is fluidly coupled to the fluid intensifier and isconfigured to receive pressurized fluid from the fluid intensifier, theside arm is movable between a closed position wherein the side arm isretracted and a guiding position wherein the side arm is extended, theside arm is configured to contact the casing in the guiding position toguide the body within the casing; and the telemetry system iscommunicatively coupled to the body, to the fluid intensifier, to thefluid jetting nozzle, and to the side arm, the telemetry systemconfigured to communicate with: the body to descend the body to acutting depth, the cutting depth being a predetermined depth within thecasing for performing the sidetracking operation, the fluid jettingnozzle to cut a window into the casing via the pressurized fluid; andthe hook to couple to the cut window and remove the cut window from thecasing.
 19. The assembly of claim 18, wherein the telemetry system iscommunicatively coupled to a drilling jar disposed within the body, andwherein the telemetry system communicates with the drilling jar togenerate an impact force onto the body.
 20. The assembly of claim 18,wherein the telemetry system is communicatively coupled to an abrasivematerial supply and to a mixing chamber fluidly coupled to the fluidintensifier and fluidly coupled to the fluid jetting nozzle, and whereinthe telemetry system communicates with the mixing chamber to: receiveabrasive material from the abrasive material supply, receive thepressurized fluid from the fluid intensifier, mix the pressurized fluidand the abrasive material, and provide the mixed pressurized fluid tothe fluid jetting nozzle.